Method and means for treatment of oil well production



July 10, 1962 J. P. WALKER ETAL METHOD AND MEANS FOR TREATMENT OIL WELLPRODUCTION 4 Sheets-Sheet 1 Filed April 13, 1959 30 GAS OUTLET T RW T EO m n mg M T u M u 0 MA d e 0 VW. L M m o 6 a M m. a 0

WELL amt-AM I INLET WATER our/.57

DRAIN A 1' TODNEY July 10, 1962 J. P. WALKER ETAL 3,043,072

METHOD AND MEANS FOR TREATMENT OF OIL WELL PRODUCTION Filed April 15,1959 4 Sheets-Sheet 2 GAS OUTLET WELL STREAM INLET INVENTORIS JA R WALK2CLAQENCE 0. eusaow ATTORNEY July 10, 1962 J. P. WALKER ETAL METHOD ANDMEANS FOR TREATMENT OF OIL WELL PRODUCTION 4 Sheets-Sheet 3 Filed April13, 1959 GAS OUTLET no 011. OUTLET J/84- WELL .S'TPEAM INLET WATER 0U TLE T- v INlfENTORIS' JAY WALKER CLARENCE 0. ezjow ATTORNEY 4 Sheets-Sheet4 \iailvlil: 2,

W T M T m M H N 0K1. N F- TLG L NA. R T M T E 0 w w w w m Y 5 L U T m AE A JI- o w w c 5 L 2 2 Y 6 a I .H I A B m T I= w Li H Mir.

Jul 10, 1962 J. P. WALKER ETAL METHOD AND MEANS FOR TREATMENT OF OILWELL PRODUCTION Filed April 13, 1959 iifididlz Patented July 30, lQ fiZa Ti 3,043,072 METHQD AND lvdlANd FUR TREATMENT QB {3E WELL PRGDUCTEGNJay P. Walker and Clarence 0. Glasgow, Tulsa, Gltla,

assignors to National Tani; Company, Tulsa, Okla, a

corporation of Nevada Filed Apr. 13, 1959, Ser. No. 896,000 7 Claims.(Cl. 5545) This invention relates to new and useful improvements inmethod and means for treating oil well emulsion streams.

The invention is directed primarily to the heater type of emulsiontreater and is particularly concerned with the efiicient and effectivecondensation of valuable light hydrocarbons from the gas evolved duringthe heating of the well stream of emulsion. Application of heat breaksthe well stream, or emulsion, into its components. Chemical mixed withthe well stream, or emulsion, furthers this process. However, somehydrocarbons are driven from a liquid state into a vapor state by thisheat. The lighter of these hydrocarbons, such as methane, ethane andpropane cannot be held in a liquid state at ambient temperature andpressure. However, heavier hydrocarbons, driven from their liquid stateby the evolvement of these lighter hydrocarbons into gas, are also indanger of being lost from the treating process as vapor. Therefore,recovery of these hydrocarbons which are liqueiiable at ambientconditions is desirable to increase both the volume and gravity of theclean oil produced.

The pressures at which well streams are produced vary widely. -i thereduction of production pressure to treating pressure is made in onestep, many liquefiable hydrocarbons may be carried away as gas and lostto the recovered liquids. Therefore, any multiplicity of pressurereduction steps helps separate the lighter hydrocarbons more slowly sofewer of the heavier hydrocarbons will be driven into the gaseous state.An intermediate result of using multiple stage separation is to provideadditional liquid hydrocarbons for the heating and stabilizitaonportions of a treating process. The ultimate result is to increase thequantity and gravity of liquefied hydrocarbons recovered at ambientconditions.

in addition to the problem of conserving both the quantity and gravityof the clean oil produced by heat treating, there is another problem inconserving the heat required for the process. Of course, it iseconomically desirable to consume and waste as little heat as possiblein the water of the well stream. Structure, and arrangement ofstructure, which will enable the heat of the source to be placeddirectly into the portion of the well stream requiring the heat fortreating, and which will keep the transfer rate near its maximum, willenable the heat source to be fired at the lowest, more efficient, rate.

A principal object of the present invention is to condense fractionsfrom all gaseous hydrocarbons evolved from heat-treating oil wellemulsions and return the hydrocarbon condensate to the heat-treatingprocess for further stabilization.

Another object is to prepare oil well emulsions for heat-treating byreducing the pressure on the emulsion so as to provide a max mum ofhydrocarbon liquid for heat-treating. The ultimate condensation of allgaseous hydrocarbons evolved from the'heat-treatment will returnadditional quantities of liquid hydrocarbons to the heat-treatingprocess for further stabilization and removal of water from the process.

Another object is to condense water vapor from all the mixture ofhydrocarbon and water vapor evolved from heat-treating oil well emulsionand maintain the condensed water isolated from the clean oil produced bythe process while disposing of the water.

Another object is to utilize the cooling capacity of oil well productionin condensing fractions from all gaseous hydrocarbons evolved fromheat-treating the production and maintain the condensed fractionsisolated from the clean oil produced while returning the condensedfractions to the production, before the production is heat treated, forfurther stabilization.

Another object is to utilize the cooling capacity of the oil wellproduction stream to condense fractions from all gaseous hydrocarbonsevolved from the heat-treating of the production and to use the oil wellproduction stream to cool the clean oil produced by the treatment and tocombine condensed hydrocarbons with the production, as the production ispassed to the heat-treatment, for further stabilization of the condensedhydrocarbons.

Another object is to provide isolation for oil and emulsion in an arealarge enough for efficient Stratification of the liquid components of awell stream in a heat treating process and heat transfer from aheatsource into the emulsion, or oil, strata to thoroughly mix theemulsion with any added chemical and degas the emulsions.

Another object is to provide for selective heating of the emulsion andoil components of a well stream while the gaseous component developed isremoved, in isolation, to a condensing location. Emulsion and oil, whichhas been heated, is continually removed from the upper portion of thestrata of the emulsion and oil and coalesced into clean oil and water.

The present invention contemplates applying heat to an oil well emulsionto resolve it into its components. All the gaseous component isindirectly cooled by a cooler stream of fluid to condense that portionof the gas which can be held in a liquid state under substantiallyambient conditions or temperature and pressure. The condensed liquid isthen cycled through the heating step to further stabilize thehydrocarbons of the liquid.

The invention further contemplates that at least one separator vessel beprovided ahead of the heat-treatment process for the oil well emulsionto stage the pressure reduction on the emulsion in separating thegaseous components. The liquid portion of the well stream is then heatedand the liquefiable components of gas evolved are cycled through theheating step to further stabilize the hydrocarbons of the liquid andremove the water from the process.

The invention further contemplates that the water vapor portion of allgaseous components evolved in the heating step will be received by apassage which will keep the condensed water isolated from the clean oiland take it to a location which is a substantial distance below thesurface of the clean oil and/ or into combination with the emulsiongoing to the heating step so it can join the other water separated fromthe well stream and removed from the process.

The invention further contemplates that fractions of all gaseoushydrocarbons evolved in the heating step will be brought into indirectheat-exchange with the oil well production to condense the fractionswhich can be held as a liquid at ambient conditions. A conduit will thenbring the collected condensate fractions to the stream of productionwhile keeping the condensate isolated from the clean oil produced. Theproduction and condensate mixture is then taken to the heat-treatingprocess so the condensed fractions may again be heated to furtherstabilize them.

The invention further contemplates flowing the oil well productionthrough two indirect heat exchangers. The production will function as acooling medium in each exchanger, condensing fractions from all gaseoushydrocarbons evolved from the heat treating of the production andcooling the clean oil produced by the treatment. At the same time, acollection location is provided for a V I 3,043,072

3 the fractions condensed and a conduit provided to carry them intocombination with the production as it goes to the heat-treating process.This arrangement'provides a plurality. of cooling functions for theproduction and 'a fractionating cycle for all liquefiable hydrocarbonsevolved as gas from the heat-treating of the production.

The invention further contemplates flowing the oil well production intothe heating chamber of a treater vessel in which sufficient residencetime is provided to thorough- 1y mix any chemical added and to permitstratification of the oil and emulsion in a strata and free water in aseparate strata. A heat source is provided in the oil and emulsionstrata to confine the direct heat transfer from the source to the oiland emulsion strata.

The invention further contemplates that the selective heating of the'oil and emulsion strata will raise these well stream components totheir highest temperature. directly. above the source of heat andevolved substantially all the hydrocarbon gas and water vapor, whichwill evolve as gas. The gas will be taken by'conduits into heat exchangewith the cooler well stream, before the well stream is 'passed into thestratification chamber'to condense a portion of the gas and return thatcondensate to the well stream which is going to the heated strata and toa location a substantial distance below the surface of the clean oilproduced by the process. Baflies are arranged to continually draw oiland emulsion from the, top of the heated strata and direct thesecomponents downwardly and then upwardly, through a coalescing section inthe vessel.

Other objects, advantages and features of this invention will become'more apparent to one skilled in the art upon consideration of writtenspecification, appended claims, and the attached drawings, wherein:

z FIG. 1 is a diagrammatic, sectioned, elevation of an 'oil wellemulsion treater embodying the present invention;

FIG. 2 is an elevation of another treater embodying other features ofthe invention;

FIG. 3 is an elevation of another treater embodying additional featuresof the invention; and

FIG, 4 is a diagrammatic, sectioned, elevation of an oil well emulsion:treater somewhat different from the treaters of FIGS. 1, 2 and 3 andembodying some of the features of the invention.

Referring to FIG. 1, numeral 1 designates an elongated cylindrical tankextending vertically, its upper end closed by a domed head 2 and itslower end closedby a dished bottom 3. The tank is set upon asuitablesupport 4 and has an internal, transverse, horizontal partition5 near its upper end. This transverse partition 5 forms, with head 2, agas separation chamber 6.

Separator 7 moved from the shell 1 as a unit. This arrangementfacilitates cleaning and servicing the separator and replacing it withone having a different pressure'capacity. Liquid: conduit 14 is extendedupward, from separator 10, through heat exchanger 20. V V

' Although not shown in FIG. 1, separator ltlis normally structures.However, these ranges must be understood to depend upon subjectivecharacteristics of the well stream and the equipment available toprocess the well stream. 7

The pressure at which the treating in vessel-tank 1 is carried out maybe in theorder of 10 to 15 lbs. per sq. in. If a high pressureseparator, not shown in FIG. 1, is available, it may be operated withina range of 600 to 800 lbs. per sq. in. A general objective of stagingthe pressure reduction is to carry out each stage of reduction justbelow the base of the retrograde pressure range. There are pointsrelative to the retrograde pressure range at which an optimum release ofthe lighter methane, ethane and propane gases can be brought about witha minimum release of the heavier hydrcarbons in the form of gas. Ingeneral, adding stages of pressure reduction at these points willproduce larger quantities of hydrocarbon liquid available for thetreating process.

An additional advantage in staging the pressure reduction ahead of thetreating vessel 1 is found in lowered costs for the fabrication of thetreating vessel 1 itself. With the higher pressures in the separatorsahead of tank 1, tank 1 need only be as thick in wall size as requiredfor retention of the well fluids at a low treating pressure.

With separator 10 mounted in the lower portion of 1 shell 1, anadditional advantage is found in the heat exchange between the warmfluids within the shell 1 and the colder fluids of the well stream. Whenthe entire heat balance requirements of thesystem have been properlyconsidered the fluids of separator 10 may be protected from freezing,due to low ambient temperatures, by being warmed with the fluids of'tank1.

Returning to a consideration of the immediate function of separator 10on thewell stream, the well stream is seen to be spun and deflected bydiverter structure 12 into its gaseous and liquid phases. So separated,the

gaseous phase is discharged through conduit 13 to a sales Separator 163may serve a gas sales lien which operates at lbs. per sq. in. Backpressure valve 21 may be set to open at 60. lbs. per sq. in, being fullyopened at 65 lbs. per sq. in. Under normal conditions of operation,there will be both a liquid and gas flow through separator 10, the gaspressure building up in separator 10 above 5Q lbs. so that continuousdelivery through conduit 13, and its valve 15, will take place. Theliquid level will rise in separator 10 and actuate float 16 to closevalve 15 until thepressure in separator 10 reaches lbs. per sq. in. At60 lbs. per sq. in. valve 21 will begin to open and the liquids willflow to the top of tank 1 if the 60 lbs.

.per sq. in. is high enough to overcome the hydraulic 1 head and thetreating pressure held on treater tank 1.

expected to be part of. a complete system for staging the pressurereduction of the well stream from the wellhead to the treating processoftankl. Several pressure ranges may be recited to illustrate therelation between the 7 Should the liquid level in separator 10 continueto increase, valve 15 will be closed further, developing the pressure inseparator 10 above 60 lbs. per sq. in. neces-- sary to flow the liquidphase to the separator section 6.

Shouldthe liquid level in separator 10 continue to rise and lift float16 valve 15 will be closed and liquid will he positively-prevented fromgoing out gas conduit 13. Should the liquids in separator 10 'deceraseto a very smallamount, gas valve 15 will be opened wide so that gas willalways be discharged through conduit 13 and normally fail to build thepressure up to the setting of valve 21' and thereby escape into theseparator section 6 in the top of the treater.

H eat Exchanger 20 tubes telescoped within each other concentrically.Liquid conduit 14 is arranged as the inner tube.

Arranged concentrically about conduit 14 is conduit 22 which removesliquid from separation chamber 6 downwardly through heat exchanger 20.The liquids removed from separator 6 by conduit 22., are taken to a heattreating process in the lower part of vessel 1 and just above thelocation of separator 16.

Arranged concentrically about both conduit 14 and conduit 22 is conduit23. Downcomer conduit 23 removes the clean oil produced by heat treatingprocess within tank-vessel 1 and heat exchanges it with the well streamof conduit 22 to conserve heat introduced in the heat treating process.

Heat Exchanger 25 Conduit 14 is extended out of the top of the otherconduits 22 and 23 of heat exchanger 26 to connect with heat exchanger25 mounted within separation chamber 6. Comparable to heat exchanger 2%,heat exchanger 25 is made up of three concentric tubes. Tube 26constitutes the outer shell of heat exchanger 25 and receives conduit 14at its lower end. Conduit 27 is connected to the upper end of tube 26and to a diverter plate 28, mounted on the inner wall of chamber 6. Thisparticular arrangement of tube 26, in heat exchanger 25, permits theindirect contact of the incoming well stream with all of the gaseousproducts developed by the subsequent heat treating of this same wellstream within vessel 1. The liquids of conduit 14 are thus passed upthrough heat exchanger 25 and into diverter 28 to be spread out on thewall of the upper part of the shell of the treater vessel 1 in chamher6. Gas is separated from the well stream by this action and carried outof the vessel 1 through a mist extractor structure 29 and outlet conduit36.

As stated before tube 26 constitutes the outside shell of heat exchanger25 in separation chamber 6. From within tube 26 another tube isconcentrically telescoped Within a third tube in order to bring all gasevolved in the heat treatment of the liquid well stream into indirectcontact with the liquids before these liquids are heat-treated.Specifically, tube 31 extends downwardly from heat exchanger 25, throughtransverse partition 5 to a point well below the surface of the cleanoil produced by the process.

Telescoped up inside of tube 31 is tube 32 which brings the gasesevolved directly from heat treating process up into exchanger 25. Holes33 are provided in the Wall of tube 31, just below partition 5, to bringgaseous vapors developed above the surface of the clean oil up intoseparation chamber 6.

Just below heat exchanger 25, connected to conduit 31, is a conduit '34.Conduit 34 takes all or" the uncondensed vapor from both conduits 31 and32 through indirect heat exchange with the well stream liquids fromdiverter 28 which have collected in the bottom of chamber 6. After thisheat exchange, the gases which are still not condensed are ejected intothe gaseous space of chamber 6, passing out mist extractor 23 throughconduit 36.

Heat exchanger 25 functions to bring all of the gaseous hydrocarbons andwater vapor developed in the heat treating process of the well streaminto indirect heat exchange contact with the relatively cool liquids ofthe well stream before the Well stream is taken to the heat treatingprocess. As gaseous hydrocarbons and Water vapor rise within centralheat exchange conduit 32, a portion of the products which can beliquefied condense out and fall back in conduit 32 or conduit 31. Ineither event, the water condensed is maintained consistently isolatedfrom the clean oil produced by the heat treating process. This Water isremoved to a point well below the surface of the clean oil and descendsto the bottom of vessel 1 for removal through a conduit.

The hydrocarbons and water vapor which are not condensed as they risewithin conduits 31 and 32 continue to be cooled as they pass throughconduit 34. Further condensation of these vapors occur and these liquidsflow back down conduit 34 and conduit 32, remaining isolated from theclean oil. As these liquids are deposited well below the surface of theclean oil, the hydrocarbon distillate will join the clean oil and riseto the point of exit while the water will continue to descend forseparate removal and not contaminate the clean oil product.

Conduit 34, functionally, is a continuation of the heat exchangesurfaces of exchanger which continues the function of condensation byheat exchange with the liquids collected on the bottom of chamber 6.Finally, the gaseous products which have been stripped of all componentswhich are storageable at ambient conditions, as liquid, are removed fromgas outlet 30.

H eating Zone 41 Attention is now redirected to the well stream liquidscollected on the bottom of chamber 6 and flowing down conduit 22.Conduit 22 liquids are introduced, by conduit 43', into a heating zone41 in the lower portion of vessel ll, directly above separator 16. Afiretube 42 is shown, representing a source of heat for zone 41.Firetube 42 may take any of several well known conventional forms.Conventionally, these firetubes are supplied the products of combustionof gas taken from gas outlet conduit 3i When gas outlet does not havesufficient as for this heating, another source of gas must be supplied.

Heating zone 41 is formed about firetube 42 by a hood 43 and bafiie 44.Hood 43 has a depending skirt, or lip, closely positioned to verticalbaflle 44. Battle 44 is extended well below firetube 42 in order to formthe heating zone 41 about firetube 42 which Will contain only emulsifiedoil and water to be directly heated by firetube 42.

Maintaining firetube 4-2 immersed in oil, Within heating zone 41, givesan opportunity for the thermal currents developed by the firetube tocompletely mix and roll the emulsion. This function would not beaccomplished if the emulsion was simply passed up over the tube immersedin water. Thus the heat is applied to that portion of the Well streamwhere it is most needed to break the emulsion between oil and water. Thefree water is not heated and heat is not thereby wasted in heating thewater.

A large portion of the hydrocarbon fractions and water which can beevolved in the heating process is driven from the well stream 'at thelocation above firetube 42 in zone 41 and passes up conduit 32 to heatexchanger 2-5. Only the upper, hottest, portions of the heated emulsionin zone 41 is removed to pass upwardly through the agglomerating sectionof the treater. The depending skirt or bafile of hood 43, and transversebafile 44, are arranged to skim the uppermost layer of the emulsion inzone 41 and pass this heated emulsion downwardly and release it upwardlyso that it will flow upwardly toward the agglomerating, or filter,section, while any solid foreign matter and water will flow downwardlyto the bottom of the treater.

The emulsion heated in zone 41 is released from hood 43 only after ithas attained the highest temperature possible by the firing of tube 42.This heated emulsion is completely prepared for treating byagglomerating section 45. The treating is then completed by the oilbeing coalesced and the water being coalesced within section 45. Theclean oil produced is passed to a point above filter section 45 tocollect in a body, and the water coalesced gravitates downwardly to beremoved through water outlet conduit 46.

FIG. 2 is used to illustrate a treater quite similar to that shown inFIG. 1. A tank has a head 51 and bottom 52 with a support 53. Atransverse partition 54 defines a separating chamber 55 in the upper endof the tank 50.

There is no relatively high pressuretseparator shown in the bottom oftank 50. If required, a separator similar to that'in FIG. 1 may beemployed to receive the well stream and pass its liquids to inletconduit 60.. Thus it 7 is that a separator similar to 10 of FIG. 1 neednot be incorporated in the treater. However, if such a separator is notemployed the advantages of its use are not realized.

Heat Exchanger 61 Inlet conduit 60 passes the liquids-of the well streaminto separator chamber 55, after they pass through heat exchanger 61.Heat exchanger 61 provides conduits 62 and 63 about conduit 60 in orderto conserve the heat of the process by transferring a considerableportion of the heat from the clean oil produced to emulsion taken to theheat treating section of tank 50.

H eat Exclzanger 65 Heat exchanger 65 in separating chamber 55, is quitesimilar to heat exchanger in providing a means whereby the relativelycool incoming well stream can be used to cool all of the liquefiablecomponents of the gases evolved from the heating process. Further, thestructure of heat exchanger 65 correspondingly provides for keep- 7 ingliquids condensed by the cooling isolated from the clean oilproductwhile talc'ng these liquids to a point where they can be releasedto separate into oil and water. The oil joins the clean oil product ofthe process while water is directed into combination with waterdeveloped during the heat treating.

. evolved from the coalescing section of the treater, above the hotclean oil product, it is desirable that the water vapor portion of thisgas not be condensed and dropped into the clean 'oil as it leaves thetreater. Bafile 66 is provided below partition 54 as an illustration ofan insulating head which avoids condensation of this evolved gas at thispoint. The uncondensed gas flows into'holes 67 in conduit 68 where thecondensate formed will be kept isolated from the clean oil and becarried to a point where the water can join the other water developed intreating and be disposed of without contaminating the clean oil.

Heating Zone 70 Conduit 62 is shown removing the liquids of separatingchamber to heating zone70. In heating zone 70 the' emulsion of the wellstream is held in a comparatively large body where it isfraised to itshighest temperature in the process while being given a much longerretention time in the body than heretofore available in prior artstructures. The advantage of 'this function of the large, isolated,heating zone has already been developed in describing the similarheating zone 41 of FIG. 1. r

The heated emulsion is continuously drawn from the top of the zone 70and directed downwardly and then upwardly'toward the coalescing section.If any sand, or other foreign matter, has been carried to this point of.heated emulsion removal from the zone 70 the final'reversal of directionof its flow will tend to throw solid foreign matter downwardly from theheated emulsion. The heated emulsion will then rise upwardly through thecoalescing section of the treater to collect in a clean body of oil.-The clean body of oil is removed from above coalescing section 71through conduit 63 where the heat place. The gas. evolved above theclean oil is carried out holes 67 as previously described.

Referring to H6. 3,- there has been shown a treater tank 72 quitesimilar to the tanlevessels of the proceeding figures. A head 73 and abottom 74 are provided as in the other structures; The entire tank restson a support 75 and a transverse partition 76 provides the upperseparation chamber 77. V V c Again, an integral high pressure separatoris not disclosed as mounted in the bottom of tank 70. The well stream isbrought to the treater through conduit 80 and passes through heatexchanger 81 which is quite similar to the heat exchangers'of FIGS. 1and 2 In distinguishment from the preceding structures, conduit 80 doesnot pass through heat exchanger 81 and pass the well stream directlyinto separation chamber 77. Rather, a tube sheet 32 and a tube sheet 8 3are provided across conduit 84 which conduit is concentric about conduit 8t A plurality of tubes 85 extend upward from the tube sheet 83 toterminate at tube sheet 86. The result is to form a heat exchangerbetween tube sheets 83 and 86 into which the well stream is passed onthe tube side.

The heat exchanger, external of tank 72,.between dam sheets 83 and 86brings the. well stream and substantially all the evolved gases of theheating process together for condensation of the liquefia'ble componentstherefrom. Both water vapor and; hydrocarbon fractions may be condensedand fall back to a point well below the surface of the clean oil. 7However, some "condensation will also occur within the heat exchangerbetween dam sheets 83' and S6. The condensed liquids could, be removedto a point in the coalescing section, at least well below the clean oilsurface. Conduit 87 is here provided to continually draw off thesecondensates and pass them into. conduit 84, below dam sheet 82, so thatthey will mix with the liquids of the well stream going to the heattreatment process in the lower part of vessel 72. This arrangementprovides a recycling of the condensible hydrocarbons and water throughthe heat treating process, for disposal of the water and furtherstabilization of the hydrocarbons.

That portion of the gas which does not liquefy in the heat exchangerbetween dam sheets 83 and 86 is removed from the shell side of the heatexchanger by means of conduitflih Conduit 90 merely represents one meanswhereby these uncondensed gaseous products of the heat treating processare joined with those gaseous. products separated in chamber 77 to passout of the tre'ater through 'is passed upward'through conduit 92.

Tray 94;

Gas 'evolvedfrom the coalescing section of the treater and collectingabove the clean oil surface may contain water vapor which it would notbe desirable 'to condense back into the clean oil product. Condensationcan be avoided by insulating the gas from the cooled underside ofpartition 76. Tray 94- offers an alternate to insulation.

Tray 94 is provided beneath partition 76. with risers 9.5, whichpass thegas rising from the top of the clean oil up into contact with the cooledhead 76. Condensate formed on partition 76 will fall'and collect on tray94 and flow into conduit 93 through holes 916. Gas which does notcondense'is drawn up conduit 93 through holes 97.

The gas from conduit 2 and the gas from conduit 93 is combined inconduit 98. if Conduit 98 passes these gases into, the shell side of theheat exchanger between dam sheets 83 and 86. Should condensation occurin either conduit 92 or 93, the liquids will fall back into the heat:treating processwell below the clean oilsurface-while remainingcompletely isolated therefrom. No possibility-1 of contamination bycondensed water ispossible.v "The condensates are either placed in thecoalescing section of the .treater or are placed in the emulsion goinginto the heat treating process in the lower portion of the treater. Ineither event, cutting of the quality of the clean oil produced isavoided and placing the hydrocarbon fractions in the emulsionadditionally provides for their continual restabilization.

The well stream passing out of the plurality of tubes 85 into the upperportion of conduit 84 above darn sheet 86 is spread on the internalwalls of separation chamber 77 by diverter 100. The diverter 1% isplaced near conduit 93 so that the liquids of the well stream dischargedfrom diverter 100 will cool conduit 93 and condense the gases collectedtherein. The liquids fall into a collection above transverse partition76 and are drawn into conduit 84 and downwardly into the lower part oftank 72.

Transverse partition 101 is part of a particular form of water knockoutand emulsion spreader. A central hole 102 is provided in partition 101,about which two circular battles are concentrically arranged. The outercircular battle 103 is provided with a hole 194 near its juncture withpartition 101 and on the side opposite the discharge point of emulsionfrom conduit 84. The inner, concentric, partition 1135 has serrations onits lower edge. The emulsion distributed under partition 101 is retardedand distributed in a strata by circular partition 103 and dischargedfrom this strata through hole 104. Emulsion through the hole 104 isdirected downwardly and then upwardly over the serrations of circularpartition 1495. Free water which has been developed by the preheating inheat exchanger 81 and in the strata under partition 101, is starteddownwardly while the emulsion is flowed upwardly over firetube 106.

Firetube 196 is located beneath a hood 107 in an arrangement similar tothe preceding drawings. Hood 107, with its depending skirt, andtransverse bathe 108, provide all the advantages of the large capacityheating zone as described in connection with the prior structures.

The heated emulsion is drawn from beneath hood 1G7 and into coalescingsection 109. The gas developed by this heating is drawn upwardly throughconduit 92 for condensation as previously described. Clean oil abovecoalescing section 109 is drawn downwardly through heat exchanger 81 andout conduit 110.

Referring now to FIG. 4; there is shown a tank 120 with a domed head 121and a dished bottom 122, all resting on a support 123.

No high pressure separator or external liquid-liquid heat exchanger isdisclosed. These features can be combined with the structure, however,it is anticipated that a wide range of types of oil well production canbe handled successfully without employing these features in this form oftreater.

The oil Well production is brought into tank 120 through conduit 125.Conduit 125 places the well stream in heating zone 126, very similar tothe heating zones of the preceding disclosures,

Hood 127, with depending skirt, is used to define heating zone 126, inco-operation with transverse bafiie 128. Flume 129 extends upwardly fromhood 127 to carry ofi the majority of gaseous components developed bythe direct heating of the well fluids in heating zone 126 by firetube130.

The well stream flowing in at the bottom of the treater through conduit125 drops its free water to the bottom of the treater. The oil andemulsion of the well stream is then heated in zone 126 with firetube 130immersed in the emulsion and oil. The thermal currents created by thisheating causes an agitation of the oil to remove entrained gas, and atthe same time creates good chemical mixing and more even distribution ofchemical in the oil to promote efficient treating. The gas developed isconducted up the center flume 129.

The gas going up fiume 129 is taken into a dome 131 1% mounted on thetop of head 121. Baffies 132 break up any foam that may have beendeveloped. Conduit 133 draws off the developed gas and fins 134 aremounted on conduit 133 to dissipate the heat from this gas and condensehydrocarbon fractions and Water Vapor from the gaseous mixture,

The condensed liquids in conduit 133 drop straight down to a pointwithin the coalescing section of the treater, remaining isolated fromthe clean oil. The gas which is not liquefied passes out conduit 135 andgas outlet 136.

Any gas evolved above the clean oil collected above the coalescingsection joins the fiume 12% gas and the mixture flows out gas outlet136. The condensate iskept isolated from the clean oil by conduit 133and drops to the coalescing section.

From the foregoing it will be seen that thisinvention is one welladapted to attain all of the ends and objects hereinabove set forth,together with other advantages which are obvious and which are inherentto the method and apparatus.

It will be understood that certain features and subcombinations are ofutility and may be employed without reference to other features andsubcom binations. This is contemplated by and is within the scope of theclaims.

As many possible embodiments may be made of the invention withoutdepartment from the scope thereof, it is to be understood that allmatter herein set forth or shown in the accompanying drawings is to beinterpreted as illustrative and not in a limiting sense.

The invention having been described, What is claimed 1s:

1. A system of treating oil Well production, including.

a heat source controlled to heat the production and break it into oiland Water and gas,

a collector for evolved gas directly above the heat source,

a first conduit from the collector for the evolved gas,

a coalescing section receiving the oil and emulsion prepared by theheater for coalescence,

a chamber for collecting the clean oil produced from the coalescencesection,

a second conduit extending into the gas space above the clean oil in theclean oil chamber which removes the evolved gas from above the clean oiland maintains any Water condensed in the second conduit isolated fromthe clean oil in the clean oil chamber as the clean oil is produced fromthe chamber,

a third conduit connected to the first and second conduits for combiningthe gas of the first and second conduits,

a heat exchanger connected to the third conduit and bringing theproduction into heat exchange with the combined gas to condenser thatportion of the combined gas which can be held in a liquid state undersubstantially ambient conditions,

and a fourth conduit for the condensate of the heat exchanger with whichthe condensate is removed from the heat exchanger and mixed with theproduction going to the heat source to further stabilize thehydrocarbons of the condensate.

2. A system of treating oil Well production, including a heat sourcewhich is controlled so it will heat the production and separate it intooil and water and a collector directly above the heat source for gasevolved by heating the production to the highest temperature it attainsin the system,

a first conduit connected to the collector for removing the evolved gasfrom the collector,

a coalescing section receiving the production remaining in a liquidstate as the production is withdrawn from the collector,

a chamber in which clean oil section is collected,

a first heat exchanger connected to the clean oil produced by thecoalescing 11 chamber to bring the clean oil and production'ifi heatexchange with each other prior to the production beingiheat ed by thecontrolled heat source,

a second conduit connected to the gas space above the clean'oil in theclean oil chamber Which receives gas evolved from the clean oil, v a

a second heat exchanger connected to the first and second conduits tobring all the gaseous components evolved by the controlled heat sourceinto heat exchange with the production prior to the production beingheated by the controlled heat source,

a third conduit connected to the second conduit to receive watercondensed in the second conduit and keep the water isolated from theclean oil produced by the coalescing section while returning the waterto the coalescing section from where the water gravitates downwardly fordisposal,

and a fourth conduit receiving the condensate of the second heatexchanger and placing the condensate into the production as it goes tothe controlled heat source, whereby the hydrocarbons of the condensateare further stabilized.

3. The method of treating oil well production, comrsrng,

collecting the production into a volume sufiiciently large to permitstratification of the oil and emulsion into a strata and free water intoa separate strata,

directing heat into the oil and emulsion strata which will evolve gas,

continuously withdrawing oil and emulsion from the heated strata as itis raised to a maximum temperature,

coalescing the oil and water of the oil and emulsion strata after it hasbeen raised to the maximum temperature to produce clean oil,

condensing water and hydrocarbons from all vapors evolved above thesurface of the coalesced oil,

condensing water and hydrocarbons from all vapors evolved from directlyheating the oil and emulsion strata,

maintaining all the condensed Water and hydrocarbons from all thesevapors isolated from the clean oil,

flowing a first portion of the isolated water and hydrocarbons beneaththe surface of the clean oil,

and flowing the remainder of the isolated water and hydrocarbons to thelarge volume of collected production.

4. An oil well production treater, including,

a source of oil well production delivering production into the treaterfor heat treatment,

baflles within the treater providing a volume receiving the productionand sufficiently large to permit stratification of the oil and emulsioninto a strata and free water into'a separate strata,

a source of heat mounted in the oil and emulsion strata to direct heatinto the strata which will evolve gas,

means for flowing the hottest portion of the strata of oil and emulsionfrom the large volume,

a coalescing section in the treater receiving the hottest portion of thestrata of oil and emulsion to produce the clean oil asthe treateroutput,

means for condensing water and hydrocarbon from all vapors evolved abovethe surface of the coalesced oil, 7

means for condensing water and hydrocarbons from all vapors evolved fromthe directly heated oil and emulsion strata, V

and a conduit system for keeping all the condensed water andhydrocarbons isolated from the clean oil while carrying a first portionof the isolated water and hydrocarbons below the surface of the cleanoil and the remaining condensates to the large volume of production. Y

5. A system for treating oil Well production, including,

a heat exchanger for receiving all a heat source controlled to heat theproduction and a chamber for collecting the clean oil produced from thecoalescence section,

a second conduit extending upwards into the gas space above the cleanoil in the clean oil chamber to remove the gas evolved from above theclean oil and extending downward a substantial distance below the cleanoil surface to maintain any water condensed in the second conduitisolated from the clean oil in the clean oil chamber as the clean oil isproduced from the chamber and take the water condensed in the conduit toa location a substantial distance below the a clean oil surface. 7 V

a third conduit connected to the first and second conduits for combininggas of the first and second conduits,

a heat exchanger connected to the third conduit and bringing theproduction into heat exchange with the combined gas to condense thatportion of the combined gas which can be held in a liquid state undersubstantially ambient conditions, a

and a fourth conduit for the condensate of the heat exchanger with whichthe condensate is removed from the heat exchanger and mixed with theproduction going to the heat source to further stabilize thehydrocarbons of the condensate.

6. ,An oil well production treater including,

a source of oil Well production delivering production into the treaterfor heat treatement,

r a source of heat mounted within the treater for heating a coalescingsection above the heat source and below the separator chamber abovewhich a body of clean oil is produced as a product of the treater,

an insulation means between the gas space above the body of clean oiland the separator to keep the cooler fluid stream of production in theseparator chamber from condensing the warmer gas evolved from thecoalescing section,

the gas evolved from the coalescing section for cooling by theproduction before the production is passed to the source of heat,

and a conduit system for keeping all the condensed -water andhydrocarbons isolated from the clean oil While carrying a first portionof the isolated water and hydrocarbons below the surface of the cleanoil and the remaining condensates to the large volume of production.

7. An oil well production treater including,

a source of oil well production delivering production into the treaterfor heat treatment,

a source of heat mounted within the treater for heating the oil wellproduction,

a separator chamber above the heat source receiving separator passingall the warmer gas evolved from the coalescing section into heatexchange with the separator chamber and collecting the condensate,

a first conduit system for receiving gases evolved immediately followingheating of the production by the source of heat and those gases notcondensed on the ment for restabilization of the hydrocarbons of thecondensate.

References Cited in the file of this patent UNITED STATES PATENTS2,528,032 Candler et a1 Oct. 31, 1950 2,765,917 Francis Oct. 9, 19562,948,352 Walker et a1. Aug. 9, 1960

